Field of the Invention
[0001] The invention relates to the transportation and regasification of liquefied natural
gas (LNG).
Background of the Invention
[0002] Natural gas typically is transported from the location where it is produced to the
location where it is consumed by a pipeline. However, large quantities of natural
gas may be produced in a country in which production by far exceeds demand. Without
an effective way to transport the natural gas to a location where there is a commercial
demand, the gas may be burned as it is produced, which is wasteful.
[0003] Liquefaction of the natural gas facilitates storage and transportation of the natural
gas. Liquefied natural gas ("LNG") takes up only about 1/600 of the volume that the
same amount of natural gas does in its gaseous state. LNG is produced by cooling natural
gas below its boiling point (-259° F at ambient pressures). LNG may be stored in cryogenic
containers either at or slightly above atmospheric pressure. By raising the temperature
of the LNG, it may be converted back to its gaseous form.
[0004] The growing demand for natural gas has stimulated the transportation of LNG by special
tanker ships. Natural gas produced in remote locations, such as Algeria, Borneo, or
Indonesia, may be liquefied and shipped overseas in this manner to Europe, Japan,
or the United States. Typically, the natural gas is gathered through one or more pipelines
to a land-based liquefaction facility. The LNG is then loaded onto a tanker equipped
with cryogenic compartments (such a tanker may be referred to as an LNG carrier or
"LNGC") by pumping it through a relatively short pipeline. After the LNGC reaches
the destination port, the LNG is offloaded by cryogenic pump to a land-based regasification
facility, where it may be stored in a liquid state or regasified. To regasify the
LNG, the temperature is raised until it exceeds the LNG boiling point, causing the
LNG to return to a gaseous state. The resulting natural gas then may be distributed
through a pipeline system to various locations where it is consumed.
[0005] For safety, ecological, and/or aesthetic considerations, it has been proposed that
regasification of the LNG take place offshore. A regasification facility may be constructed
on a fixed platform located offshore, or on a floating barge or other vessel that
is moored offshore. The LNGC may either dock or be moored next to the offshore regasification
platform or vessel, and then offloaded by conventional means for either storage or
regasification. After regasification, the natural gas may be transferred to an onshore
pipeline distribution system.
[0006] It also has been proposed that regasification take place onboard the LNGC. This has
certain advantages, in that the regasification facility travels with the LNGC. This
can make it easier to accommodate natural gas demands that are more seasonal or otherwise
vary from location to location. Because the regasification facility travels with the
LNGC, it is not necessary to provide a separate LNG storage and regasification facility,
either onshore or offshore, at each location at which LNG may be delivered. Instead,
the LNGC fitted with regasification facilities may be moored offshore and connected
to a pipeline distribution system through a connection located on an offshore buoy
or platform.
[0007] When the regasification facility is located onboard the LNGC, the source of the heat
used to regasify the LNG may be transferred by use of an intermediate fluid that has
been heated by a boiler located on the LNGC. The heated fluid may then be passed through
a heat exchanger that is in contact with the LNG. An Example of it is disclosed in
US 6 089 022. Further
WO 01/03793 discloses an LNG carrier with a submerged heat exchanger.
[0008] It also has been proposed that the heat source be seawater in the vicinity of the
LNGC. As the temperature of the seawater is higher than the boiling point of the LNG
and the minimum pipeline distribution temperature, it may be pumped through a heat
exchanger to warm and regasify the LNG. However, as the LNG is warmed, regasified,
and superheated, the seawater is chilled as a result of the heat transfer between
the two fluids. Care must be taken to avoid cooling the seawater below its freezing
point. This requires that the flow rates of the LNG that is being warmed and the seawater
being used to warm the LNG be carefully controlled. Proper balancing of the flow rates
is affected by the ambient temperature of the seawater as well as the desired rate
of gasification of the LNG. Ambient temperature of the seawater can be affected by
the location where the LNGC is to be moored, the time of year when delivery occurs,
the depth of the water, and even the manner in which the chilled seawater from warming
the LNG is discharged. Moreover, the manner in which the chilled seawater is discharged
may be affected by environmental considerations, i.e., to avoid having an undesirable
environmental impact in terms of ambient water temperature depression in the vicinity
of the chilled seawater discharge. This can affect the rate at which the LNG can be
heated, and therefore the volume of LNG that can be gasified in a given period of
time, for the regasification equipment on board the LNGC.
Summary of Invention
[0009] In one aspect, the present invention relates to an LNGC having a regasification system
that includes one or more submerged heat exchangers moveably fixed onboard an LNG
carrier, such that the heat exchanger is configured to be lowered into water for use,
an on-board vaporizer for vaporizing the LNG, and an intermediate fluid that circulates
through the vaporizer and the submerged heat exchanger.
[0010] In another aspect, the invention relates to a regasification system for an LNGC,
including an on-board vaporizer for vaporizing the LNG and a submerged heat exchanger
that is connected to the LNGC after the LNGC reaches the off-loading terminal.
Brief Description of Drawings
[0011]
Figure 1 is a schematic of a prior art keel cooler system.
Figure 2 is a schematic of a submerged heat exchanger used as a source of heat for
the vaporizer.
Figure 3 is a schematic of an alternative dual heat source system.
Detained Description
[0012] Various improvements can be made to the manner in which LNG is regasified aboard
an LNGC. Specifically, there are other sources of heat, components for heat transfer,
and combinations of heat sources, that can be used to provide additional flexibility
with respect to the locations and the environmental impact of the onboard LNGC regasification.
[0013] Devices commonly referred to as "keel coolers" have been used in the past to provide
a source of cooling for marine equipment, such as propulsion engine coolers and air
conditioning. As shown in FIG. 1, the keel cooler
2 is a submerged heat exchanger that typically is located on or near the bottom of
the ship's hull
1, and uses ocean water as a "heat sink" for the heat generated by onboard equipment
(such as marine air conditioning units
3) that requires cooling capacity.
[0014] The keel cooler
2 operates by either using one or more pods (not shown) that are either built into
the lower part of the hull
1 or attached to the exterior of the hull 1 as a heat exchanger that cools an intermediate
fluid (such as fresh water or a glycol) that is circulated by pump 1 through the pod.
This intermediate fluid is then pumped to one or more locations on the ship to absorb
excess heat.
[0015] Among the advantages of such a system, as compared to a system that brings in and
subsequently discharges seawater to use as a cooling fluid, is the reduced sinking
hazard and corrosion hazard that is associated with the circulation of the seawater
to various locations onboard the ship. Only the exterior of the keel cooler pod
2 is exposed to the seawater, fresh water, or another relatively non-corrosive fluid
that is circulated through the remainder of what amounts to a closed system. Pumps,
piping, valves, and other components in the closed loop system do not need to be manufactured
from more exotic materials that would be resistant to sea water corrosion. Keel coolers
2 also obviate the need for filtering the seawater, as may be required in a system
that passes seawater into the interior of the shipboard machinery components.
[0016] As shown in FIG. 2, in one preferred embodiment of the invention, one or more submerged
heat exchangers
21 are employed - not to provide cooling capacity, but instead to provide heating capacity
for the closed loop circulating fluid, which in turn is used to regasify the LNG.
[0017] One or more submerged heat exchanger units
21 may be located at any suitable location below the waterline of the hull
1. They may be mounted directly within the hull
1 of the LNGC, or mounted in one or more separate structures connected to the LNGC
by suitable piping. For example, the submerged heat exchanger system may be mounted
to the buoy that is used to moor the LNGC. Alternatively, the heat exchangers may
be partially, rather than fully, submerged.
[0018] An intermediate fluid, such as glycol or fresh water, is circulated by a pump
22 through the vaporizer
23 and the submerged heat exchanger
21. Other intermediate fluids having suitable characteristics, such as acceptable heat
capacity and boiling points, also may be used and are commonly known in the industry.
LNG is passed into the vaporizer
23 through line
24 where it is regasified and exits through line
25.
[0019] The submerged heat exchangers
21 enable heat transfer from the surrounding seawater to the circulated intermediate
fluid without the intake or pumping of sea water into the LNGC, as mentioned above.
The size and surface area of the heat exchangers
21 may vary widely, depending upon the volume of LNG cargo being regasified for delivery
and the temperature ranges of the water in which the LNGC makes delivery of natural
gas.
[0020] For example, if the temperature of the circulated intermediate fluid is approximately
45 °F upon return to the submerged heat exchanger
21 and the seawater temperature is about 59 °F, the temperature differential between
the two is about 14 °F. This is a relatively modest temperature differential, and,
accordingly, the heat exchanger
21 will require a larger surface area to accommodate the heat transfer needs of the
present invention, as compared to the typical keel coolers described above, which
were designed for the rejection of a few million BTUs per hour. In one preferred embodiment,
a submerged heat exchanger
21 designed to absorb approximately 62 million BTUs per hour is used and has approximately
450,000 square feet of surface area. This quantity of surface area may be arranged
in a variety or configurations, including, in the preferred embodiment, multiple tube
bundles arranged similarly to those in conventional keel coolers. The heat exchanger
21 of the present invention may also be a shell and tube heat exchanger, a bent-tube
fixed-tube-sheet exchanger, spiral tube exchanger, falling-film exchanger, plate-type
exchanger, or other heat exchangers commonly known by those skilled in the art that
meet the temperature, volume and heat absorption requirements for the LNG to be regasified.
[0021] In addition, the heat exchanger
21, instead of being mounted in the ship, may be a separate heat exchanger
21 that is lowered into the water after the LNG vessel reaches its offshore discharge
facility; or it may be a permanently submerged installation at the offshore discharge
facility. Either of these alternative heat exchanger
21 configurations is connected to the LNGC so as to allow the intermediate fluid to
be circulated through the submerged heat exchanger
21.
[0022] The vaporizer
23 preferrably is a shell and tube vaporizer, and such a vaporizer
23 is schematically depicted in FIG. 2. This type of vaporizer
23 is well known to the industry, and is similar to several dozen water heated shell
and tube vaporizers in service at land-based regasification facilities. In alternative
shipboard applications, where seawater may be one of the heating mediums or may contact
the equipment, the vaporizer
23 is preferably made of a proprietary AL-6XN super stainless steel (ASTM B688) for
wetted surfaces in contact with sea water and type 316L stainless steel for all other
surfaces of the vaporizer
23. A wide variety of materials may be used for the vaporizer, including but not limited
to titanium alloys and compounds.
[0023] In the preferred embodiment, a shell and tube vaporizer
23 is used that produces about 100 million standard cubic feet per day ("mmscf/d") of
LNG with a molecular weight of about 16.9. For example, when operating the LNGC in
seawater with a temperature of about 59 °F and the intermediate fluid temperature
is about 45 °F, the vaporizer
23 will require a heated water flow of about 2,000 cubic meters per hour. The resulting
heat transfer of approximately 62 million BTUs per hour is preferably achieved using
a single tube bundle of about forty foot long tubes, preferably about ¾ inch in diameter.
Special design features are incorporated in the vaporizer
23 to assure uniform distribution of LNG in the tubes, to accommodate the differential
thermal contraction between the tubes and the shell, to preclude freezing of the heating
water medium, and to accommodate the added loads from shipboard accelerations. In
the most preferred embodiment, parallel installation of 100 mmscf/d capacity vaporizers
23 are arranged to achieve the total required output capacity for the regasification
vessel. Suppliers of these types of vaporizers
23 in the U.S. include Chicago Power and Process, Inc: and Manning and Lewis, Inc.
[0024] In the preferred embodiment of the invention, the circulating pumps
22 for the intermediate fluid are conventional single stage centrifugal pumps
22 driven by synchronous speed electrical motors. Single stage centrifugal pumps
22 are frequently used for water/fluid pumping in maritime and industrial applications,
and are well known to those skilled in the art. The capacity of the circulating pumps
22 is selected based upon the quantity of vaporizers
23 installed and the degree of redundancy desired.
[0025] For example, to accommodate about a 500 million standard cubic feet per day ("mmscfld")
design capacity, a shipboard installation of six vaporizers
23, each with a capacity of about 100 mmscf/d, is made. The required total heating water
circulation for this system is about 10,000 cubic meters per hour at the design point,
and about 12,000 cubic meters per hour at the peak rating. Taking shipboard space
limitations into consideration, three pumps
22, each with a 5,000 cubic meter per hour capacity are used and provide a fully redundant
unit at the design point circulation requirements of 10,000 cubic meters per hour.
These pumps
22 have a total dynamic head of approximately 30 meters, and the power requirement for
each pump
22 is approximately 950 kW (kilowatts). The suction and discharge piping for each pump
22 is preferably 650 mm diameter piping, but pipe of other dimensions may be used.
[0026] The materials used for the pumps
22 and associated piping preferrably can withstand the corrosive effects of seawater,
and a variety of materials are available. In the preferred embodiment, the pump casings
are made of nickel aluminum bronze alloy and the impellers have Monel pump shafts.
Monel is a highly corrosive resistant nickel based alloy containing approximately
60 - 70% nickel, 22 - 35% copper, and small quantities of iron, manganese, silicon
and carbon.
[0027] While the preferred embodiment of the invention is drawn to a single stage centrifugal
pump
22, a number of types of pumps
22 that meet the required flow rates may be used and are available from pump suppliers.
In alternative embodiments, the pumps
22 may be smooth flow and pulsating flow pumps, velocity-head or positive-displacement
pumps, screw pumps, rotary pumps, vane pumps, gear pumps, radial-plunger pumps, swash-plate
pumps, plunger pumps and piston pumps, or other pumps that meet the flow rate requirements
of the intermediate fluid.
[0028] A submerged or partially submerged heat exchanger system
21 may be used as either the only source of heat for regasification of the LNG, or,
in an alternative embodiment of the invention as shown in FIG. 3, may be used in conjunction
with one or more secondary sources of heat. In the event that the capacity of the
submerged or partially submerged heat exchanger system
21, or the local sea water temperature, are not sufficient to provide the amount of heat
required for the desired level of regasification operations, this embodiment of the
invention provides operational advantages.
[0029] In one preferred alternative embodiment, the intermediate fluid is circulated by
pump
22 through steam heater
26, vaporizer
23, and one or more submerged or partially submerged heat exchangers
21. In the most preferred embodiment of the invention, the heat exchanger
21 is submerged. Steam from a boiler or other source enters the steam heater
26 through line
31 and exits as condensate through line
32. Valves 41,
42, and
43 permit the isolation of steam heater
26 and the opening of bypass line
51, which allows the operation of the vaporizer
23 with the steam heater
26 removed from the circuit. Alternatively, valves
44, 45, and
46 permit the isolation of the submerged heat exchanger
21 and the opening of bypass line
52, which allows operation of the vaporizer
23 with the submerged heat exchanger
21 removed from the circuit.
[0030] The steam heater
26 preferrably is a conventional shell and tube heat exchanger fitted with a drain cooler
to enable the heating of the circulated water, and may provide either all or a portion
of the heat required for the LNG regasification. The steam heater
26 is preferrably provided with desuperheated steam at approximately 10 bars of pressure
and about 450 °F temperature. The steam is condensed and sub-cooled in the steam heater
26 and drain cooler and returned to the vessel's steam plant at approximately 160 °F.
[0031] In another alternative embodiment, the heating water medium in the steam heater
26 and drain cooler is sea water. A 90-10 copper nickel alloy is preferrably used for
all wetted surfaces in contact with the heating water medium. Shell side components
in contact with steam and condensate are preferrably carbon steel.
[0032] For the shipboard installation described above, three steam heaters
26 with drain coolers are used, each preferably providing 50% of the overall required
capacity. Each steam heater
26 with a drain cooler has the capacity for a heating water flow of about 5,000 cubic
meters per hour and a steam flow of about 30,000 kilograms per hour. Suitable steam
heat exchangers
26 are similar to steam surface condensers used in many shipboard, industrial and utility
applications, and are available from heat exchanger manufacturers worldwide.
[0033] The addition of a seawater inlet
61 and a seawater outlet
62 for a flow through seawater system, permit seawater to be used as either a direct
source of heat for the vaporizer
23 or as an additional source of heat to be used in conjunction with the steam heater
26, instead of the submerged heat exchangers
21. This is shown in
FIG. 3 by the dashed lines.
[0034] Alternatively, the submerged or partially submerged heat exchanger system
21 may be used as the secondary source of heat, while another source of heat is used
as the primary source of heat for regasification operations. Examples of another such
source of heat would include steam from a boiler, or a flow-through seawater system
in which seawater is introduced as a source of heat from the ocean (or other body
of water in which the LNGC is located) and discharged back into the ocean after being
used to heat either the LNG or an intermediate fluid that subsequently is used to
heat the LNG. Other sources of heat could include a submerged combustion vaporizer
or solar energy. Having a secondary or alternative source of heat in addition to the
primary source of heat, whether or not either of the sources is a submerged heat exchanger
system, also is considered advantageous.
[0035] The use of a primary source of heat coupled with the availability of at least one
secondary source of heat provides additional flexibility in the manner in which the
LNG may be heated for regasification purposes. The primary source of heat may be used
without requiring that source of heat to be scaled up to accommodate all ambient circumstances
under which the regasification may take place. Instead, the secondary source of heat
may be used only in those circumstances in which an additional source of heat is required.
[0036] The availability of a secondary source of heat that is based on an entirely different
principal than the primary source of heat also guarantees the availability of at least
some heat energy in the event of a failure of the primary heat source. While the regasification
capacity may be substantially reduced in the event of a failure of the primary source
of heat, the secondary source of heat would provide at least a partial regasification
capability that could be used while the primary source of heat is either repaired
or the reason for the failure otherwise corrected.
[0037] In one embodiment of such a system, the primary source of heat may be steam from
a boiler, and the secondary source a submerged heat exchanger system. Alternatively,
the primary source of heat may be steam from a boiler, and the secondary source may
be the use of an open, flow-through seawater system. Other combinations of sources
of heat also may be used depending on availability, economics, or other considerations.
Other potential heat sources include the use of hot water heating boilers, intermediate
fluid heat exchangers, or submerged combustion heat exchangers, each of which are
commercially available products.
[0038] In another embodiment of the system, the LNGC may be equipped with a primary heat
source, and made ready for the addition of a secondary heat source by including piping
and other items that otherwise could require substantial modification of the ship
to accommodate. For example, the LNGC could be equipped to use steam from a boiler
as the primary source of heat, but also be equipped with suitable piping and locations
for pumps or other equipment to facilitate the later installation of a submerged heat
exchanger system or a flow-through seawater system without requiring major structural
modification of the ship itself. While this may increase the initial expense of constructing
the LNGC or reduce the capacity of the LNGC slightly, it would be economically preferable
to undergoing a major structural modification of the ship at a later date.
[0039] The preferred method of this invention is an improved process for regasifying LNG
while onboard an LNG carrier. The LNGC, fitted with regasification facilities as described
above, may be moored offshore and connected to a pipeline distribution system through
a connection located on an offshore buoy or platform, for example. Once this connection
is made, an intermediate fluid, such as glycol or fresh water, is circulated by pump
22 through the submerged or partially submerged heat exchanger
21 and the vaporizer
23. Other intermediate fluids having suitable characteristics, such as acceptable heat
capacity and boiling points also may be used as described above. The heat exchanger
21 is preferably submerged and enables heat transfer from the surrounding seawater to
the circulated intermediate fluid due to the temperature differential between the
two. The intermediate fluid, thereafter circulates to the vaporizer
23, which preferably is a shell and tube vaporizer. In the preferred embodiment, the
intermediate fluid passes through parallel vaporizers to increase the output capacity
of the LNGC. LNG is passed into the vaporizer
23 through line
24, where it is regasified and exits through line
25. From line
25, the LNG passes into a pipeline distribution system attached to the platform or buoy
where the LNGC is moored.
[0040] In another method of the invention, the intermediate fluid is circulated through
submerged heat exchangers
21 that are mounted in one or more structures connected to the LNGC by suitable piping.
In yet another alternative method of the invention, the submerged heat exchangers
21 are mounted to the buoy or other offshore structure to which the LNGC is moored,
and connected to the ship after docking.
[0041] In another preferred method of the invention, one or more secondary sources of heat
are provided for regasification of the LNG. In one embodiment, the intermediate fluid
is circulated by pump
22 through steam heater
26, vaporizer
23, and one or more submerged or partially submerged heat exchangers
21. Steam from a boiler or other source enters steam heater
26 through line
31 and exits as condensate through line
32. Valves
41, 42 and
43 permit operation of the vaporizer
23 with or without the steam heater 26. In addition, the vaporizer
23 may be operated solely with use of the secondary sources of heat such as the steam
heater
26. Valves
44, 45, and
46 permit isolation of these submerged heat exchangers
21, so that the vaporizer
23 may operate without them.
[0042] In another method of the invention, a flow through seawater system, with an inlet
61 and an outlet
62, permit seawater to be used as a direct source of heat for the vaporizer
23 or as an additional source of heat to be used in conjunction with the steam heater
26, instead of the submerged heat exchanger
21. Of course, the submerged or partially submerged heat exchanger system
21 may be used as a secondary source of heat, while one of the other described sources
of heat is used as the primary source of heat. Examples of this are described above.
[0043] Various exemplary embodiments of the invention have been shown and described above.
However, the invention is not so limited. Rather, the invention shall be considered
limited only by the scope of the appended claims.